CN103980950A - Apparatus and method to produce synthetic gas - Google Patents
Apparatus and method to produce synthetic gas Download PDFInfo
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- CN103980950A CN103980950A CN201410049689.7A CN201410049689A CN103980950A CN 103980950 A CN103980950 A CN 103980950A CN 201410049689 A CN201410049689 A CN 201410049689A CN 103980950 A CN103980950 A CN 103980950A
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/22—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by diffusion
- B01D53/225—Multiple stage diffusion
- B01D53/226—Multiple stage diffusion in serial connexion
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2256/00—Main component in the product gas stream after treatment
- B01D2256/16—Hydrogen
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2256/00—Main component in the product gas stream after treatment
- B01D2256/20—Carbon monoxide
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/30—Sulfur compounds
- B01D2257/304—Hydrogen sulfide
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/50—Carbon oxides
- B01D2257/504—Carbon dioxide
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
- Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
- Y02E60/30—Hydrogen technology
- Y02E60/32—Hydrogen storage
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P30/00—Technologies relating to oil refining and petrochemical industry
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Abstract
A system and method of capturing carbon dioxide from a flow of raw synthesis gas generated in a gasification system are provided. The carbon capture system includes an acid gas removal subsystem configured to generate a flow of reduced acid gas content syngas, a flow of hydrogen sulfide (H2S) lean gas, and a first flow of H2S-rich gas from a stream of particulate-free raw syngas, an H2S selective membrane separator, said H2S selective membrane separator configured to separate the flow of H2S-lean gas from the AGR into a second flow of H2S-rich gas and a flow of CO2 gas, and a sulfur recovery unit (SRU) coupled in flow communication with said H2S membrane separator downstream of said membrane separator, said SRU configured to generate a flow of elemental sulfur and a flow of tail gas from the first flow of H2S-rich gas and the second flow of H2S-rich gas.
Description
Technical field
The field of the invention relates generally to equipment for gasification, exactly, relates to a kind of method and apparatus, and described method and apparatus uses the synthetic gas of equipment for gasification to produce by hydrogen sulfide is separated to improve from synthetic air-flow with carbonic acid gas.
Background technology
At least some known equipment for gasification comprise gasification system, and described gasification system is together with at least one power generation turbine system integration, thus formation integral type gasification combination circulation (IGCC) generating set.For example, known gasification system is by fuel, air or oxygen, steam and/or CO
2mixture convert synthesis gas to, i.e. synthetic gas.Synthetic gas is transported in the burner of gas turbine engine, and described burner will drive generator, and described generator is supplied electric power to power network.The exhaust of at least some known gas turbine engines is fed to heat recovery steam generator (HRSG), and described heat recovery steam generator produces the steam for driving steam turbine.The electric power that described steam turbine produces also drives generator, and described generator supplies power to power network.
Produce at the beginning with device-dependent at least some the known gasification systems of IGCC " raw material (raw, or be called " untreated ", " untreated ") " synthetic gas fuel, it comprises carbon monoxide (CO), hydrogen (H
2), carbonic acid gas (CO
2), nitric sulfid (COS) and hydrogen sulfide (H
2s).CO
2, COS and H
2s is commonly referred to sour gas.Conventionally sour gas is removed from material synthesis gas fuel, to produce " cleaning " synthetic gas fuel for burning in gas turbine engine.
Summary of the invention
In one embodiment, the invention provides a kind of carbon capture system, described carbon capture system comprises: acid gas removal (AGR) subsystem, described acid gas removal subsystem configures is for synthesizing air-flow, poor hydrogen sulfide (H from producing low content of acid gas without the synthetic air-flow of particulate material
2s) air-flow and the first rich H
2s air-flow; H
2s selectivity membrane separator, described H
2s selectivity membrane separator is oriented in the downstream of described AGR subsystem, described H
2s selectivity membrane separator is configured for the poor H from described AGR
2s pneumatic separation becomes the second rich H
2s air-flow and CO
2air-flow; And sulfur recovery unit (SRU), described sulfur recovery unit is at described membrane separator downstream and described H
2s membrane separator fluid is communicated with, and described SRU is configured for from the first rich H
2s air-flow and the second rich H
2s air-flow produces elementary sulfur stream and tail gas stream.
In another embodiment, the invention provides a kind of raw synthesis gas stream producing from gasification system and catch carbonic acid gas (CO
2) method, described method comprises: at H
2the ingress of at least one in S selectivity membrane separator and acid gas removal unit (AGR) receives and comprises CO
2raw synthesis gas stream; Use described AGR from described raw synthesis gas stream and poor H
2at least one in the synthetic air-flow of S isolated relatively clean synthetic gas; Use H
2at least one in raw synthesis gas stream and acid gas stream is separated into rich H by S selectivity membrane separator
2s air-flow and poor H
2s air-flow; And use sulfur recovery unit (SRU) from rich H
2in S gas, isolate sulphur.
In another embodiment, the invention provides a kind of gasification system, described gasification system comprises: gasifier, and described gasifier is configured for and produces the fuel gas stream that comprises sour gas; Acid gas removal subsystem (AGR), described acid gas removal subsystem is communicated with described gasifier fluid, and is configured for from described fuel gas stream and removes at least a portion sour gas; Membrane separator, described membrane separator is communicated with described acid gas removal subsystem fluid, described membrane separator is oriented at least one place in the upstream and downstream of described acid gas removal subsystem along the direction of fuel gas stream, described membrane separator is configured for hydrogen sulfide (H
2s) gas and described fuel gas flow point from, to produce rich H
2s air-flow and poor H
2s air-flow; And sulfur recovery unit (SRU), described sulfur recovery unit is communicated with described membrane separator fluid in described membrane separator downstream, and described SRU is configured for from rich H
2in S air-flow, remove sulphur.
Brief description of the drawings
Fig. 1 shows the exemplary embodiment of method and apparatus described in this specification sheets to Fig. 6.
Fig. 1 is the schematic diagram of gasification system according to an illustrative embodiment of the invention;
Fig. 2 is the block diagram that the parts of gasification system shown in Fig. 1 are according to an illustrative embodiment of the invention arranged;
Fig. 3 is the block diagram that the parts of gasification system shown in Fig. 1 are according to an illustrative embodiment of the invention arranged, wherein tail gas recirculation in gasification system;
Fig. 4 is the block diagram that the another kind of parts of gasification system shown in Fig. 1 are according to an illustrative embodiment of the invention arranged; And
Fig. 5 is the block diagram that the another kind of parts of gasification system shown in Fig. 1 are according to an illustrative embodiment of the invention arranged;
Fig. 6 is the block diagram that the parts of gasification system shown in the Fig. 1 of another exemplary embodiment according to the present invention are arranged.
Embodiment
Below describe in detail with example but infinite mode has been described embodiments of the invention.It should be understood that the present invention is applied to conventionally in industry, the application of business and house catches the carbonic acid gas (CO in air-flow
2).
In this manual, employing singulative and element or step with " one " or " one " modification are interpreted as not getting rid of multiple described elements or step, unless this type of eliminating is made and being clearly stated.In addition, the present invention's " embodiment " reference is not intended to be interpreted as getting rid of the extra embodiment that existence comprises described feature equally.
In the time using with reference to barrier film, in this specification sheets, term " selectivity " used has been described for other components in mixture, and a kind of component in barrier film permission mixture is by the tendency of barrier film.Therefore, CO
2selectivity barrier film is for example, with respect to other components in mixture, H
2s and H
2, preferably allow CO
2the barrier film passing through.
Fig. 1 is the schematic diagram of integral type gasification combination circulation (IGCC) generating set 100 according to an illustrative embodiment of the invention.In the exemplary embodiment, IGCC generating set 100 comprises gas turbine engine 110.Gas turbine 114 is connected to the first generator 118 by the first rotor 120 in rotatable mode.Gas turbine 114 and at least one fuel source and at least one air source (both all as detailed below) fluid is communicated with, and is configured for respectively from fuel source and air source reception fuel and air.Gas turbine 114 is configured for mixing air with fuel, generation high-temperature combustion gas (not shown) and the thermal power transfer in gas is become to rotation energy.Described rotation can be transported to generator 118 by rotor 120, and wherein generator 118 is configured for and promotes can convert rotation to be transported at least one load electric energy (not shown), and described load includes, but not limited to power network (not shown).
IGCC generating set 100 also comprises steam turbine engines 130.In the exemplary embodiment, engine 130 comprises steam turbine 132, and described steam turbine is connected to the second generator 134 by the second rotor 136 in rotatable mode.
IGCC generating set 100 further comprises steam generating system 140.In the exemplary embodiment, system 140 comprises at least one heat recovery steam generator (HRSG) 142, and described heat recovery steam generator is communicated with at least one heat transfer equipment 144 fluid to water conduit 146 by least one heating boiler.HRSG142 is configured for by conduit 146 slave units 144 and receives oiler feed (not shown), to promote that oiler feed is heated into steam.HRSG142 is also configured for by exhaust guide 148 and receives exhaust from turbine 114, further to promote that oiler feed is heated into steam.HRSG142 is communicated with turbine 132 fluids by steam duct 150.Excess air and steam will be discharged into atmosphere from HRSG142 by stack gas conduit 152.
Conduit 150 is configured for steam is transported to turbine 132 from HRSG142.Turbine 132 is configured for from HRSG142 and receives steam and the thermal power transfer steam is become to rotation energy.Described rotation can be transported to generator 134 by rotor 136, and wherein generator 134 is configured for and promotes can convert rotation to be transported at least one load electric energy (not shown), and described load includes, but not limited to power network.Described vapor condensation and return to (not shown) as feedwater by condensation product conduit.
IGCC generating set 100 also comprises gasification system 200.In the exemplary embodiment, gasification system 200 comprises at least one air gas separation unit (ASU) 202, and described air gas separation unit is communicated with air source 203 fluids by air lead 204.Air source 203 includes, but not limited to special-purpose air compressor and compressed-air-storing unit.ASU202 is configured for air separation is become to oxygen (O
2), nitrogen (N
2) and other components.Other components discharge by ventilation hole (not shown).N
2pass through N
2conduit 206 is transported to gas turbine 114, to promote burning.
Gasification system 200 comprises gasifying reactor 208, and described gasifying reactor is communicated with ASU202 fluid, and is configured for and passes through O
2conduit 210 receives O from ASU202
2steam.System 200 also comprises coal grinding and slurrying unit 211.Unit 211 is communicated with coal source 205 and water source 207 fluids by coal supply conduit 212 and water supply conduit 213 respectively.Unit 211 is configured for coal and water is mixed to form coal slurry steam, and described coal slurry steam is transported to reactor 208 by coal slurry conduit 214.Although coal is illustrated as fuel supply source, any carbonaceous material can be used as to the fuel of gasification system 200.
Reactor 208 is configured for respectively and receives coal slurry steam and O by conduit 214 and 210
2steam.Reactor 208 is also configured for and promotes to produce high temperature material synthesis gas body (synthetic gas) steam.Material synthesis gas comprises carbon monoxide (CO), hydrogen (H
2), carbonic acid gas (CO
2), carbon oxysulfide (carbonyl sulfide, COS) and hydrogen sulfide (H
2s).Although CO
2, COS and H
2s is referred to as sour gas conventionally, or the acid gas components of material synthesis gas, in this manual, and CO
2will with all the other acid gas components separate introductions.In addition, reactor 208 is also configured for and produces the by product that high temperature furnace slag stream is produced as synthetic gas.Described slag stream is transported to slag treatment unit 215 by high temperature furnace slag conduit 216.Unit 215 is configured for and slag is quenched or be broken into little furnace clinker, wherein produces slagging-off stream (slag removal stream) and carries this slagging-off stream by conduit 217.
Reactor 208 is communicated with heat transfer equipment 144 fluids by high-temperature synthesis gas conduit 218.Equipment 144 is configured for and receives high temperature raw synthesis gas stream and by conduit 146, at least a portion heat be delivered to HRSG142.Afterwards, equipment 144 produces cooling raw synthesis gas stream (not shown), and described raw synthesis gas stream is transported to washer by synthetic gas conduit 219 and cryogenic gas cooling (LTGC) unit 221.LTGC221 is configured for the particulate matter being entrained in raw synthesis gas stream is removed, and promotes to remove this material of removing by flying dust conduit 222.LTGC221 is also configured for further cooling raw synthesis gas stream.In addition, LTGC221 can be configured for and comprise one or more shift-converters, and described shift-converter is by CO and H
2o converts CO to
2and H
2, and can convert a part of any COS to H
2s and CO
2.LTGC221 can be configured for and comprise COS hydrolysis reactor, to convert at least a portion COS in raw synthesis gas stream to H by hydrolysis
2s and CO
2.In addition, LTGC221 can be configured for and comprise one or more superheaters, more than guaranteeing that material synthesis gas product is maintained to dew point.
System 200 further comprises acid gas removal (AGR) subsystem 300, and described acid gas removal subsystem 300 is communicated with LTGC221 fluid, and is configured for by material synthesis gas conduit 220 and receives cooling raw synthesis gas stream.AGR300 is also configured for and promotes from raw synthesis gas stream, to remove at least a portion acidic components (not shown), as detailed below.This type of acid gas components includes, but not limited to CO
2, COS and H
2s.AGR300 is further configured for and promotes at least a portion acid gas components to be separated into multiple components, includes, but are not limited to CO
2, COS and H
2s.
In multiple embodiment, AGR300 can use following material operation: such as, but not limited to, physical absorbent, ethylene glycol sorbent material or
or Ryan-
; Based on the material of chemosorbent, such as MEA, MDEA, TEA etc.; Or other AGR technology, for example non-specific sour gas barrier film or CO
2special isolation film.AGR300 can also use such as the sorbent material such as TEA or MDEA and be incorporated to, to produce high pressure, potential high-purity CO from AGR300
2stream, thus reduce and catch the CO that will seal (sequestration) up for safekeeping
2relevant downstream compression requirement.AGR300 can also comprise the dehydrating step for removing water, and/or the oxidation step in AGR downstream, to use suitable cooling and knockout drum (knock-out drum, KOD) to produce CO
2stream, this depends on CO
2end-use.
In addition, AGR300 is communicated with sulfur recovery unit (SRU) 400 fluids by conduit 223.SRU400 is also configured for and receives and promote that at least number acid gaseous fraction is separated into multiple components, includes, but not limited to CO
2, COS and H
2s, and again convert sulfur component to elementary sulfur, to discharge from conduit 401.In addition, AGR300 and/or SRU400 can be configured for by final synthetic gas stream (not shown) being transported to reactor 208 such as AGR300 and final synthetic gas stream conduit 224 etc.Final synthetic gas stream comprises the CO of the predetermined concentration that above-mentioned synthetic gas stream (not shown) produces
2, COS and H
2s, as detailed below.In multiple embodiment, SRU400 can use the Arbitrary Term in following to implement: claus process (Claus process), direct sulfur recovery technique (DSRP), sulfuric acid, direct oxidation, sulphuring treatment (Sulfatreat) direct oxidation, sulphuring treatment and RTI Zn base sulfur removal technology.
AGR300 is communicated with reactor 208 fluids by conduit 224, and wherein final synthetic gas stream is transported to the predetermined portion of reactor 208.Separate and remove this type of CO with SRU400 by AGR300
2, COS and H
2s contributes to produce clean synthetic air-flow (not shown), and described synthetic air-flow will be transported to gas turbine 114 by clean synthetic gas conduit 228.
In operation, air gas separation unit 202 is by conduit 204 admission of airs.Described air will be separated into O
2, N
2with other components.Described other components are discharged by ventilation hole, N
2be transported to turbine 114 by conduit 206, and O
2be transported to gasifying reactor 208 by conduit 210.In addition, in operation, coal grinding and slurrying unit 211 receive coal by conduit 212 and 213 respectively and water, formation coal slurry flow and by conduit 214, described coal slurry stream be transported to reactor 208.
Reactor 208 receives O by conduit 210
2, receive coal and receive final integrated gas stream by conduit 224 from AGR300 by conduit 214.Reactor 208 promotes to produce high temperature raw synthesis gas stream, and described high temperature raw synthesis gas stream is transported to equipment 144 by conduit 218.The slag by product of reactor 208 interior formation removes by slag treatment unit 215 and conduit 216 and 217.Equipment 144 promotes cooling down high-temperature raw synthesis gas stream to produce cooling raw synthesis gas stream, described cooling raw synthesis gas stream is transported to washer and LTGC221 by conduit 219, wherein particulate matter by conduit 222 from synthetic gas remove, synthetic gas further cooling and at least a portion COS convert H to by hydrolysis
2s and CO
2.By cooling material synthesis gas, can reclaim the heat energy in material synthesis gas, the form for example feeding water with heated boiler.In addition, the heat energy of recovery can be in other techniques, and such as, but not limited to, conversion or other reactors, for example COS is hydrolyzed or methanation process, and the inlet streams that heating enters diaphragm cell is in order to avoid the condensation in barrier film.Cooling raw synthesis gas stream is transported to AGR300, and wherein acid gas components removes substantially, to form clean synthetic air-flow and to be transported to gas turbine 114 by conduit 228.
In addition, in operation, at least a portion acidic components that remove in synthetic air-flow can be transported to SRU400 by conduit 223, and wherein acidic components are removed.
In addition, in operation, turbine 114 receives N by conduit 206 and 228 respectively
2with clean synthetic gas.Turbine 114 burn synthetic gas fuel, produce high-temperature combustion gas and carry this high-temperature combustion gas so that turbine 114 rotates, described turbine rotates the first generator 118 by rotor 120 subsequently.
At least a portion heat removing from high-temperature synthesis gas by heat transfer equipment 144 is transported to HRSG142 by conduit 146, and water is heated into steam by wherein said heat.Described steam is transported to steam turbine 132 by conduit 150, and turbine 132 is rotated.Turbine 132 rotates the second generator 134 by the second rotor 136.
H
2s selectivity membrane separator 600 comprises for gas stream being separated into rich H
2s air-flow and poor H
2the barrier film of S air-flow.In one embodiment, H
2s selectivity membrane separator 600 is placed between LTGC221 and AGR300.In another embodiment, H
2s selectivity membrane separator 600 is placed between AGR300 and SRU400.
Fig. 2 is the schematic diagram that the another kind of parts of IGCC generating set 100 are according to an illustrative embodiment of the invention arranged.In this exemplary embodiment, cooling raw synthesis gas stream is transported to H from LTGC221
2s selectivity membrane separator 600, is then transported to AGR300.Through H
2the rich H of the barrier film (not shown) in S selectivity membrane separator 600
2s air-flow 602 is transported in SRU400, and wherein sulphur 508 separates and be transported to down-stream system to be further processed with tail gas 510.Poor H
2s air-flow 604 also comprises the synthetic gas that is transported to AGR300, wherein CO
2with poor H
2h is sealed and/or be used as to S pneumatic separation and recirculation up for safekeeping for elsewhere, the preparation of IGCC generating set 100
2the sweep gas (sweep gas, or title residual gas) of S selectivity membrane separator 600.Sweep gas is applied to H
2the low-tension side of S selectivity membrane separator 600 septations is to limit through H
2the CO of S barrier film
2loss and raising H
2s separation efficiency.In multiple embodiment, N
2and/or clean synthetic gas is also for H
2s selectivity membrane separator 600 scans (sweep).In one embodiment, CO
2selectivity barrier film 249 will enter the cooling poor H of AGR300 for promoting from conduit 220
2s gas is separated into clean synthetic air-flow and acid gas stream.
In multiple embodiment, LTGC221 can comprise and converts COS to H
2conversion/COS hydrolyzable moiety of S.
Fig. 3 is the schematic diagram that the another kind of parts of IGCC generating set 100 are according to an illustrative embodiment of the invention arranged.In the present embodiment, tail gas stream 510 is transported to tail gas hydrogenation unit 512, and wherein tail gas stream 510 is processed with recirculation in IGCC generating set 100.For example, treated tail gas 514 can be recycled to reactor 208, LTGC221, AGR300, SRU400 and/or H
2s selectivity membrane separator 600.In multiple embodiment, material synthesis gas, from H
2the synthetic gas of S selectivity membrane separator 600 and from the synthetic gas of AGR300 for tail gas hydrogenation process.In one embodiment, CO
2selectivity barrier film 249 is for by synthetic gas and sour gas and enter the cooling poor H of AGR300 from conduit 604
2s synthetic gas separates.
Fig. 4 is the schematic diagram that a kind of parts of the IGCC generating set 100 of another exemplary embodiment according to the present invention are arranged.In the present embodiment, H
2s selectivity membrane separator 600 is placed at the position that between AGR300 and SRU400, fluid is communicated with.In one embodiment, CO
2selectivity barrier film 249 will enter the cooling poor H of AGR300 for promoting from conduit 220
2s synthetic gas is separated into clean synthetic air-flow and acid gas stream.Comprise sour gas from AGR300 expellant gas, comprising CO
2, COS and H
2s, the ratio of these gases is based on multiple processing parameters, includes, but not limited to the efficiency for the shift-converter part of fuel, technological temperature and the LTGC221 of IGCC generating set 100.H
2s selectivity membrane separator 600 allows H
2s diffuses through barrier film, substantially stops other gases to diffuse through described barrier film simultaneously.Enter H by conduit 223
2the sour gas of S selectivity membrane separator 600 is separated into by conduit 500 from H
2the rich H that S selectivity membrane separator 600 is discharged
2s air-flow and by conduit 504 from H
2the poor H that S selectivity membrane separator 600 is discharged
2s air-flow.Poor H
2a part for S air-flow is recycled to H
2the upstream side of S selectivity membrane separator 600, to promote to reduce the CO through barrier film
2loss amount.
Rich H
2s gas delivery is to SRU400, and it is by rich H
2s pneumatic separation becomes elementary sulfur stream 508 and tail gas stream 510, wherein still comprises CO
2, SO
2and H
2s.Tail gas stream 510 is transported to hydrogenation unit 512, and wherein tail gas stream 510 is processed to be recycled in IGCC generating set 100.For example, treated tail gas 514 can be recycled to reactor 208, LTGC221, AGR300, SRU400 and/or H
2s selectivity membrane separator 600.
Fig. 5 is the schematic diagram that a kind of parts of IGCC generating set 100 are according to an illustrative embodiment of the invention arranged, wherein tail gas is not recycled in IGCC generating set 100.On the contrary, tail gas stream 510 is transported to another system (not shown) to process.
Fig. 6 is the schematic diagram that a kind of parts of the IGCC generating set 100 of another exemplary embodiment according to the present invention are arranged.In the present embodiment, raw synthesis gas stream 606 is transported to the entrance 608 of LTGC221.Cooling is transported to AGR300 without the synthetic air-flow of particulate material from LTGC221.Usedly in this specification sheets refer to that without particle the granule content in air-flow is enough little, can not have a negative impact to components downstream or technique.Clean synthetic air-flow is transported to syngas outlet 610 from AGR300, rich H
2s gas delivery is to SRU400, and poor H
2s gas delivery is to H
2s selectivity membrane separator 600.H
2s selectivity membrane separator 600 separates poor H
2cO in S gaseous mixture
2and H
2s, wherein CO
2be transported to CO
2outlet is for elsewhere, and H
2s is transported to SRU400.SRU400 is from from AGR300 and H
2the rich H of S selectivity membrane separator 600
2in S air-flow, isolate elementary sulfur product, to produce elementary sulfur stream and tail gas stream.Described elementary sulfur is recovered for elsewhere, and tail gas stream processes in tail gas treatment process 614, is then transported in recirculating process 616.In multiple embodiment, H
2the downstream of S barrier film 600 comprises polishing step, with promote use such as, but not limited to sulphuring treatment (
) etc. technique desulfurization.
In the exemplary embodiment, AGR300 is included in and removes solvent the first flash of light (flash) before.Described flash step is for generation of being transported to H
2the poor H of S barrier film 600
2s gas.In the present embodiment, miscellaneous part used can provide the H of reduced size for above-described embodiment
2s barrier film and less simplification AGR300.
The method and apparatus for the synthesis of gas or synthetic gas production described in this specification sheets contributes to operate the circulation of integral type gasification combination (IGCC) generating set, particularly synthetic gas production system.Specifically, from synthesis gas product stream body stream, remove more hydrogen polysulfide (H
2s) and carbon oxysulfide (COS) improve synthetic gas production efficiency.Specifically, reduce to be provided to the carbonic acid gas (CO of gasifying reactor
2) H in feed streams
2s and COS concentration contribute to reduce to be transported to the impurity concentration in the clean synthetic gas of gas turbine.In addition, as described in this description, configuration integral type resorber is substantially to remove continuously H
2s and COS contribute to optimize synthetic gas production technique, to improve IGCC production efficiency of equipment, thereby are convenient to reduce running cost.In addition, for maintaining continuously resorber in running status and regulating the method for relevant gas flow can help avoid improper discharge, because reduce H
2s and COS concentration can be convenient to the operation nargin (operational margin) of the carrying capacity of environment restriction that improves these components.In addition, described in this specification sheets, can contribute to reduce for the production of the method and apparatus of this type of synthetic gas and manufacture the device-dependent cost of capital of this type of IGCC.
More than describe in detail and the device-dependent synthetic gas production of IGCC exemplary embodiment.Described method, apparatus and system are not limited to the specific embodiment described in this specification sheets, are also not limited to illustrated specific IGCC equipment.In addition, these type of method, apparatus and system are not limited to IGCC equipment, and embed in various device, generally include, but be not limited to, produce hydrogen technique, Fischer-Tropsch (Fischer-Tropsch) fuel production technique, and gasification system, synthetic natural gas system and gas cleaning system.
This specification sheets has used various examples to disclose the present invention, comprises optimal mode, and under also allowing, any technician in field can implement the present invention simultaneously, comprises and manufactures and use any device or system, and implement any method containing.Protection scope of the present invention is defined by the claims, and can comprise other examples that those skilled in the art finds out.If the textural element of other these type of examples is identical with the letter of claims, if or the letter of the equivalent structure key element that comprises of this type of example and claims without essential difference, this type of example also should be in the scope of claims.
Claims (20)
1. a carbon capture system, comprising:
Acid gas removal (AGR) subsystem, described acid gas removal subsystem configures is for synthesizing air-flow, poor hydrogen sulfide (H from producing low content of acid gas without the synthetic air-flow of particulate material
2s) air-flow and the first rich H
2s air-flow;
H
2s selectivity membrane separator, described H
2s selectivity membrane separator is oriented in the downstream of described AGR subsystem, described H
2s selectivity membrane separator is configured for the described poor H from described AGR
2s pneumatic separation becomes the second rich H
2s air-flow and CO
2air-flow; And
Sulfur recovery unit (SRU), described sulfur recovery unit is at downstream and the described H of described membrane separator
2s membrane separator fluid is communicated with, and described SRU is configured for from described the first rich H
2s air-flow and described the second rich H
2s air-flow produces elementary sulfur stream and tail gas stream.
2. system according to claim 1, further comprise shift-converter, the upstream fluid of at least one in described membrane separator and described acid gas removal subsystem of described shift-converter is communicated with, and described shift-converter is configured for and produces hydrogen (H
2).
3. system according to claim 1, further comprise carbon oxysulfide (COS) hydrolysis unit, the upstream fluid of at least one in described membrane separator and described acid gas removal subsystem of described carbon oxysulfide hydrolysis unit is communicated with, and described COS hydrolysis unit is configured for and produces H
2s and carbonic acid gas (CO
2).
4. system according to claim 1, wherein said acid gas removal subsystem comprises CO
2selectivity diaphragm element.
5. the raw synthesis gas stream producing from gasification system is caught CO
2method, described method comprises:
At H
2the ingress of at least one in S selectivity membrane separator and acid gas removal unit (AGR) receives and comprises CO
2described raw synthesis gas stream;
Use described AGR from described raw synthesis gas stream and poor H
2at least one in the synthetic air-flow of S isolated relatively clean synthetic gas;
Use H
2at least one in described raw synthesis gas stream and acid gas stream is separated into rich H by S selectivity membrane separator
2s air-flow and poor H
2s air-flow; And
Use sulfur recovery unit (SRU) from described rich H
2s pneumatic separation goes out sulphur.
6. method according to claim 5, further comprises acid gas stream is transported to described H from described AGR
2s selectivity membrane separator.
7. method according to claim 5, further comprises described rich H
2s air-flow is from described H
2s selectivity membrane separator is transported to described SRU.
8. method according to claim 5, at CO
2stream is through described H
2after S selectivity membrane separator and described AGR, from described H
2at least one in S selectivity membrane separator and described AGR carried described CO
2stream.
9. method according to claim 5, is wherein used SRU from described rich H
2in S gas, isolating sulphur comprises:
Produce tail gas stream; And
By hydrogenation unit, described tail gas stream is recycled to at least one in following: gasifier, AGR, SRU, described H
2s selectivity membrane separator and shift-converter.
10. a gasification system, comprising:
Gasifier, described gasifier is configured for and produces the fuel gas stream that comprises sour gas;
Acid gas removal subsystem (AGR), described acid gas removal subsystem is communicated with described gasifier fluid and is configured at least a portion that removes sour gas from described fuel gas stream;
Membrane separator, described membrane separator is communicated with described acid gas removal subsystem fluid, described membrane separator is oriented at least one place in the upstream and downstream of described acid gas removal subsystem along the direction of described fuel gas stream, described membrane separator is configured for from described fuel gas stream and isolates hydrogen sulfide (H
2s) gas is to produce rich H
2s air-flow and poor H
2s air-flow; And
Sulfur recovery unit (SRU), described sulfur recovery unit is communicated with described membrane separator fluid in the downstream of described membrane separator, and described SRU is configured for from described rich H
2s airflow desulphurization.
11. systems according to claim 10, wherein said membrane separator comprises H
2s selectivity barrier film.
12. systems according to claim 10, further comprise shift-converter, the upstream fluid of at least one in described membrane separator and described acid gas removal subsystem of described shift-converter is communicated with, and described shift-converter is configured for generation hydrogen.
13. systems according to claim 10, further comprise carbon oxysulfide (COS) hydrolysis unit, the upstream fluid of at least one in described membrane separator and described acid gas removal subsystem of described carbon oxysulfide hydrolysis unit is communicated with, and described COS hydrolysis unit is configured for and produces H
2s and CO
2.
14. systems according to claim 10, wherein said SRU is configured for from described rich H
2s air-flow produces elementary sulfur and tail gas stream.
15. systems according to claim 14, wherein said tail gas stream comprises at least one in following: hydrogen sulfide (H
2s), sulfurous gas (SO
2) and carbonic acid gas (CO
2), and wherein said tail gas is transported to hydrogenation unit, and described hydrogenation unit is configured for to produce and comprises H
2the treated tail gas stream of S.
16. systems according to claim 15, wherein said treated tail gas stream is transported to following at least one: gasifier, AGR, SRU, described H
2s selectivity membrane separator and shift-converter.
17. systems according to claim 10, wherein said membrane separator comprises diaphragm element and sweep gas entrance, described sweep gas entrance is configured for reception gaseous purge stream.
18. systems according to claim 17, wherein said sweep gas entrance is configured for the relatively low pressure side that gaseous purge stream is transported to described diaphragm element.
19. systems according to claim 17, wherein said sweep gas entrance is configured for the relatively low pressure side that gaseous purge stream is transported to described diaphragm element, and described gaseous purge stream comprises at least one in following: CO
2, nitrogen (N
2) and fuel gas.
20. systems according to claim 10, wherein said acid gas removal subsystem comprises CO
2selectivity diaphragm element.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US13/766588 | 2013-02-13 | ||
| US13/766,588 US8722003B1 (en) | 2013-02-13 | 2013-02-13 | Apparatus and method to produce synthetic gas |
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| Publication Number | Publication Date |
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| CN (1) | CN103980950A (en) |
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| CN109715764A (en) * | 2016-10-17 | 2019-05-03 | 托普索公司 | The gasification process recycled using sour gas |
| CN110891668A (en) * | 2017-06-19 | 2020-03-17 | 沙特***石油公司 | Method and apparatus for processing raw natural gas comprising a membrane unit and distillation |
| US11325066B2 (en) | 2017-06-08 | 2022-05-10 | Saudi Arabian Oil Company | Helium recovery from gaseous streams |
| US11548784B1 (en) | 2021-10-26 | 2023-01-10 | Saudi Arabian Oil Company | Treating sulfur dioxide containing stream by acid aqueous absorption |
| US11926799B2 (en) | 2021-12-14 | 2024-03-12 | Saudi Arabian Oil Company | 2-iso-alkyl-2-(4-hydroxyphenyl)propane derivatives used as emulsion breakers for crude oil |
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| US8722003B1 (en) | 2014-05-13 |
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